ML20127A045

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Monthly Operating Rept for May 1985
ML20127A045
Person / Time
Site: Salem PSEG icon.png
Issue date: 05/31/1985
From: Ronafalvy J, Zupko J
Public Service Enterprise Group
To:
NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
NUDOCS 8506200540
Download: ML20127A045 (21)
v • d • e


Text

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  • I AVERAGE DAILY UNIT POWER LEVEL Docket No. 50-311 Unit Name Salem # 2 Date June 10,1985 Completed by J. P. Ronafalvy Telephone 609-935-6000 Extension 4,455 Month May 1985

. Day Average Daily Power Level Day Average Daily Power Level (MWe-NET) (MWe-NET) 1 505 17 1102 2 -214 18 1099 3 0 19 1106 4 71 20 1107 5 811 21 1100 6 1073 22 1077 7 1100 23 1075 8 1089 24 1070 i 9 1087 25 1104 10 771 26 1104 11 1104 0 27 12 0 28 1080 13 0 29 1088 14 0 30 1099 15 454 31 1109 16 ~1100 Pg. 8,1-7 R1-1 1

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8506200540 850531

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PDR ADOCK 05000311 R PDR

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OPERATING DATA REPORT Docket No. 50-311 Date June 10,1985 Telephone 935-6000 Completed by J. P. Ronafalvy Extension 4455 Operating Status

1. Unit Name Salem No. 2 Notes
2. Reporting Period May 1985
3. Licensed Thermal Power (MWt) 3411
4. Nameplate Rating (Gross MWe) 1170
5. Design Electrical' Rating (Net MWe) 1115 6.- Maximum Dependable Capacity (Gross MWe)l149
7. Maximum Dependable Capacity (Net MWe) Tr06
8. If Changes Occur in Capacity Ratings (items 3 through 7) since Last Report, Give Reason N/A-
9. Power Level to Which Restricted, if any (Net MWe) N/A
10. Reasons for Restrictions, if any N/A This Month Year to Date Cumulative
11. Hours in Reporting Period 744 3623 31848
12. No. of Hrs. Reactor was Critical 606.0 1054.6 16149.2
13. Reactor Reserve Shutdown Hrs. 0 0 3533.6
14. Hours Generator On-Line 583.1 827.2 15439.3
15. Unit Reserve Shutdown Hours 0 0 0
16. Gross Thermal Energy Generated Deni) 1867901 2275719 46002755 i 17. Gross Elec. Energy Generated

. 0001) 620020 730140 15007790

! 18. Net Elec. Energy Generated (MNH) 588633 655527 14173363 1 19. Unit Service Factor 78.4 22.8 48.5 j 20. Unit Availability Factor 78.4 22.8 48.5

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21. Unit Capacity Factor (using MDC Net) 71.5 16.4 40.2
22. Unit Capacity Factor (using DER Net) 71.0 16.2 39.9
23. Unit Forced Outage Rate 21.6 74.8 41.7
24. Shutdowns scheduled over next 6 months (type, date and duration of each)

N/A l

25. If shutdown at end of Report Period, Estimated Date of Startup:

N/A

26. Units in Test Status - (Prior to Commercial Operation) :

Forecast Achieved Initial Criticality 6/30/80 8/2/80 Initial Electricity 9/1/80 6/3/81

Commercial Operation 9/24/80 10/13/81 8-1-7.R2 i

r 7 UNIT SHUTDOWN AND POWER REDUCTIONS Docket No. 50-311 ~

REPORT MONTH May 1985 Unit Nam 3 Salem No.2 -1 Date June 10,1985 J.P. Ronafalvy Telephone. 609-935-6000 Completed by Extension 4455 Method of Duration Shutting License Cause and Corrective No. Date Type Hours Reason Down Event System Component Action to-1 2 Reacto r Report Code 4 Code 5 Prevent Recurrence F 49.0 A 5 - CH PUMPXX Feedwater Pump 85-046' 4-30 Other Exciter 85-048 5-02 F 55.0 A 3 - HA RELAYX Problems .

Control Rod

,85-068 5-10 F 105.9 A 3 - IA CRDRVE' Problem 1 2 Reason 3 Method 4 Exhibit G 5 Exhibit 1 F: Forced A-Equipment Failure-explain 1-Manual Instructions Salem as S: Scheduled B-Maintenance or Test 2-Manual Scram. for Prepara- Source C-Refueling 3-Automatic Scram. tion of Data D-Regulatory Restriction 4-Continuation of Entry Sheets E-Operator Training & Licensing Exam Previous Outage for Licensee F-Administrative 5-Load Reduction Event Report

- G-Operational Error-explain 9-Other (LER) File H-Other-explain (NUREG 0161)

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MAJOR PLANT MODIFICATIONS DOCEET NO.: 50-311 REPORT MONTH MAY 1985 UNIT NAME: Sales 2 DATE: June 10, 1985 CCMPLETED BY: J. Ronafalvy TELEPEONE: 609/339-4455

2EC-1015 Component Cooling Provide =ctor operators for cc=ponent cooling water pu=ps suction header valves 2CC17 and 2CC18.

i 2EC-1242 Service Water Provide electric space heating in El. 78 Penetration Area Service Water Valve Rocms to prevent freezing of header overpressure' controls.

2EC-1564 Fire Protection Install srcke detectors in l

areas designated P2C-1, P2C-3, l P2C-4, P2C-5, P2F-1, and P2G-1.

l 2ET-1647 Equipment Qualification Add te=porary temperature monitoring equipment inside Containment at various i locations within the Auxiliary and Control Buildings.

l 2EC-1660 Chilled Water Install a 4" isolation gate valve in the chilled water

supply header irrediately i upstream of the 4" CW supply l line to 2CH62 and a 4" isolation ball valve in the chilled water return header dcwnstream of the 4" CW return from 2CE76.

2 EC-167 7. Reactor Coolant. Replace reactor coolant narrow range RTD's with l

environmentally qualified I elements .

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  • Design Change Request l

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  • DCR NO. PRINCIPLE SYSTEM SUBJECT-
2EC-1717 Environmental . Replace' existing transmitter Qualification with environmentally qualified '

Rosemount 1153D Series Model (PA-227, PA-7461) (safety injection pump discharge pressure) and PA-211 (BIT pressure) (PT-0942).

2EC-1757 Overhead Annunciator Modify delay time from 50 milliseconds to 250 milliseconds for first out annunciator panel.

2EC-1789 Various Environmentally: upgrade numerous.limitorque valve motor operators. This upgrading is to'be accomplished by the replacement of various motor operator parts with parts which are better suited for use in harsh environmental z ones .

2EC-1861 21 C/SI Lube Oil Cooler Replace existing lube oil'on No. 21 C/SI Pump with cooler of similar design-characteristics but upgraded materials of construction.

Upgraded coolers will have outer-tubesheets and. tubes of titanium material.-

2EC-1894 Main Steam Add a "Y" type strainer downstream of-2MS55 (just before restircting orifice).

The "Y" type strainer holes must be smaller than 0.125" to serve as' primary protection of the restricting orifice.

- 2 EC-1917 ' Reactor ' Coolant Replace RTD bypass loop valves-23RC 16, 17, 24,,25 & 28 Mark No. FA-17 with Mark No.

FA-131.

2EC-1946 Containment Ventilation Installation of spring assembly in the backdraft damper mechanism'of the containment fan coil units 21, 22, 23, 24 and 25.

  • Design Change Request

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  • DCR NO. PRINCIPLE SYSTEM SUBJECT

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2EC-1970 . Containment Personnel. Install caps and valving at ,

Hatch personnel hatch E. 10 0 & 130.

2EC-1975 Steam Generator Cut out and remove valves Blowdown and Drains 21-24GB7 and replace each ,

valve with a dutchman.

2EC-1989' SGFP and Turbine Lube Change the SGFP.No. 21 and 22 ,

Control Oil thrust bearing wear alarm and r trip setpoints from 8 and 12 PSI to 13 and 17 PSI respectively.

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2ET-2006 Chilled / Service Water Test application of Garlock  ;

" Turbo-Star" cartirdge type '

mechanical seal in Chiller Condenser Recirc Pump 923.

.2EC-2007- Heater Drain Pump / Install in-line flow meters,  !

Miscellaneous check. valves local pressure Condensate instrumentation and throttling  !

valves on the stuffing box.

miscellaneous condensate gland injection lines.

This istthe' removal DCR for 2EC-2010 Main-Generator and Auxiliaries the main generator, excitation,' seal oil, stator ,

-water and the H2 and CO2 I

systems.

2EC-2072 Main Steam Spring Adjust, in.a uniform manner, Hangers the cold load setting of nine l spring hangers-located on the- '

  1. 24 Main Steam Header between the reactor containment wall and the mixing bottle, to a new load setting.

2SC-0364 21B & 22B Circulators Modify condensate,. heater

-drain and circulating water -

pump motors to allow filling of oil reservoirs.

2SC-0388A. Moisture Separator Material change of 1" piping  ;

Reheater downstream of the RD95 valves

.(desuperheating supply to the main steam coil drain. tanks)..

The only piping that needs to be changed is between RD95 valves and the SW orifice.

  • Design Change Request

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'DCR 50. F?lNCIELF STS7IM SE~ZC i

i 2SC-0420 Service Water Eay f 4 E.evise =cter service vater l ccoling piping to the service j vater p=rp setcr ecclers which vill allev crick re=cral arci restcratics of piping ha=gers arci asscciated piping 6 ring zeter change cct.

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! 2SC-0949 Waste Gas Add two test cc= ectic s tc the waste Gas Systen. Cee i

l test ccrrectice between 2VG6 l

azd 2K~,~~9 c= vent heater a=6 l c=e test ec= ectier betwee 21 5 227C,27 & 21, 22, 23,'24 E33 l

i valves es the E.P. Eeader.

250-1093 Ecric Acid Syste=- Cc str:ct a perna ent platic:r E.atch Tz:1 arce.- d the 42 C=it teric acid batching +>-V, s***T2r to the cze which erese=tly exists cc l

41 U=it tcric acid batching

"->, to replace the tenperary i scaffolding cw in place. '

2SC-1163  ?.emeter Ccolant Charge reacter coclast flcw tra-=7ri tter frcer Tisher Ecrter redel (ICE 249EFE to =ev zoiel and type specified by T.cqireeri g.

2SC-1172A- Steau Generater reed Frevide a suit #1e replac+wa t

& Cecdens. ate,.Eleed fer EO-9 r_nd CK47 can-flex

Stear & Eeater Crai= valves. The ED-9 valves are I to te relecated as elese to l ' tbe ccederser as possible.

l Can-flex valves replaced by a 1 e n. , us,...

l 230-1269 Eydrege M :itori=g Install ladfer and platfcrs in Crit Ec. 2 Centairnest to gain access to 21 & 22 Eydrcger j

.eciter System senscr assembly l te perfern maister.asce.

l l 2SC-1336 Eeater Crain P=sp Frevide glard leal cff lines j frca all three beater drain l p=nps to the *:: time 3.ilding l l --

fleed sumps.

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  • Cesig: cha ge Request i

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  • DCR NO . PRINCIPLE SYSTEM SUBJECT

.2SC-1580 Main Steam Safety Remove the lever #17, the  !

Valves forked lever #22 and the spindle nut #12 on all -(20) safety valves.

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MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 REPORT MONTH.MAY 1985 UNIT NAME: Salem 2 DATE: June 10, 1985 COMPLETED BY: J. Ronafalvy TELEPHONE: 609/339-4455

  • DCR NO.- 10CFR 50.59 SAFETY EVALUATION 2 EC-06 51 The. replacement of the Service Water strainer backwash carbon steel line with a stainless steel 316 material will i not cause an accident or malfunction not previously analyzed in the Safety Analysis Report. No unreviewed l safety or environmental questions are involved.

2EC-1015 This change will not affect the function of the valves.

.The change is an enhancement. The added motor operators are seismically (Class I) and environmentally qualified.

The description in the FSAR will be modified. No  !

unreviewed safety or environmental questions are involved. l 2EC-1242 This change entails the installation of space heaters in the Service Water Valve . Room. The supports are ,

seismically qualified and the work does not involve the safe shutdown of the reactor. No unreviewed safety  !

questions or environmental questions are involved.

2EC-1564 This change expands the Fire Detection System. No' safety

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related systems are affected. No'unreviewed safety or environmental questions are involved.

2ET-16 47 This DCR installs temporary test equipment to monitor  !

ambient temperature. No unreviewed safety or l' environmental questions are involved.

2EC-1660 The.new isolation valves in the supply and return Chilled  !-

Water headers are safety related, nuclear grade, hydrotested, and leak tested prior to. installation. They will ensure system pressure integrity and isolation ability when required. These valves will operate only t under the following. conditions:  ;

1. Unit 2 Chilled Water System is down
2. Supply chilled water to the secondary non-safety  !

related area (such as when cutting the 4" Chilled ,

Water header to allow installation of other DCR  !

valves upstream) l

  • Design Change Request l

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3. To p'rovide cross-tie flow between the Units Chilled Water Systems The valves will be locked open once Unit 2 Chilled Water System is on line. There is no impact on the safety injection actuated. valves ICH-150 and 1CH-117. The flow diverted from the secondary area from.the cross-tie has been verified by calculation to have no impact on the A/C coil operation since flow must be established to satisfy the A/C coil load of both Units first and then ICH131 is cracked.and. throttled to provide any excess flow to the secondary. areas. No unreviewed safety or environmental questions are involved.

2EC-1677 This change involves the replacement of existing equipment. The system response time will be increased by 2.7 seconds. The overtemperature delta T (Table 3.'3.2 in the Tech. Specs.) will increase but by an amount less than that allowed in Table 15.1-3 of the FSAR accident analysis. The proposed 5.0 seconds response time will provide a conservative limit relative to the accident analysis of the UFSAR and will, at the same time, provide -

sufficient latitude to allow the use of presently available, environmentally qualified RTD's. Since there are no modifications to the plant or the plant-procedures, the possibility of a new or different accident from any

, accident previously evaluated is-not created. .No j unreviewed saety or environmental questions are involved.

2EC-1717 This change involves the replacement of transmitters which 1

will have the same function as the old ones. No l unreviewed safety or environmental questions are involved.

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2BC-1757 This modification will assure that the first-out panel

alarms latch only when accompanied by a valid trip signal.

l The system is not safety-related and will not affect the

safe shutdown of the plant. No unreviewed safety or environmental questions are involved.

l~ 2EC-1789 The valve motor operator modifications involves the replacement of the existing components with new components '!

i which are environmentally qualified. This DCR will not 1- alter any plant process or discharge and will not affect l

} the existing environmental impact. No unreviewed safety j j or environmental questions are involved. . 1 l

  • Design Change Request i

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  • DCR NO. 10CFR 50.59 SAFETY EVALUATION 2EC-1861 This DCR involves the installation of Lube Oil Coolers with upgraded materials. The new titanium tubes will have greater resistance to the corrosive affect of the service water. The cooler shell is constructed of 316 stainless s teel . The upgraded coolers are designed to the 1980 edition of the ASME Code - Section III, Class 3 - 1981 Summer Addenda on the tube side (contains service water) .

The shell side is designed to Division I Section VIII of the 1980 edition of the ASME code. The new coolers were purchased from the same design specification as the l original. No unreviewed safety or environmental questions are involved.

2EC-1894 The installation of the "Y" type strainer upstream of the existing restricting orifice does not create a new safety l hazard. This DCR does not alter the function of the i system. Engineering Safety Evaluation S-C-0210-MSE-277 l

addresses a substitute for a Nuclear Class III Seismic Class I "Y" strainer (which is no longer available) . No unreviewed safety or environmental questions are involved.

2EC-1917 The replacement of the valves do not alter the ability of the piping system to per:orm as designed. The replacement

valve has been evaluated as an acceptable substitute for the existing valve. The new valve meets or exceeds the I seismic, nuclear and pressure class of the exieting l

valves. The flowmoter in the loop will ensure that the required flow is not affected after replacing the valves.

No unreviewed safety or environmental questions are involved.

l l 2EC-1946 The new spring assembly will provide additional force to assist the damper mechanism in closing and is designed so that it will not prevent the damper from opening fully.

Failure of the spring will not jeopardize the operation of the damper. The spring assembly is installed external to the ductwork. A failure of the spring will not cause any mechanisms to jam. All present safety evaluations are l valid, and no new safety concerns are introduced. No unreviewed safety or environmental questions are involved.

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  • Design Change Request I

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  • DCR NO. 10CFR 50.59 SAFETY EVALUATION 2EC-1970 All realistic failure modes for this DCR have been considered but are not applicable. This change meets GDC 56 requirements and complies with safety guide #11. The design criteria of Seismic I and Nuclear Class II are met.

No unreviewed safety or environmental questions are involved.

2 EC-19 75 Due to the high blowdown rates used on the Salem Units, the No. 21 Blowdown Tank has not been used, all blowdown is being directed to either the No. 22 Condenser or No. 22 Blowdown Tank. By removing the Nos. 21-24 GB7 valves and blanking off the lines upstream of these valves, there will be no further steam leaks in this area. No unreviewed safety or environmental questions are involved.

2EC-1989 The intended function of the system will remain the same.

This change is in conformance with manufacturer's recommendation. This is a non-safety related system. No unreviewed safety or environmental questions are involved.

2EC-2006 This test does not affect any presently performed safety analysis nor does it create any new hazards. The basis for the Tech. Specs. remains unchang6d. This test modification will not alter any plant process or discharge and will not affect the existing plant environmental impact. Also, partial implementation by retrofitting each pump separately does not affect the aforementioned. No unreviewed safety or environmental questions are involved.

2EC-2007 This mcdification does not alter any plant process or discharge and will not affect the existing plant impact.

Work is to be performed on El. 100 in the Turbine Building. No unreviewed safety or environmental sacstions are involved.

2EC-2010 This modification does not alter any plant process or discharge and will not affect the existing plant impact.

No safety related systems are involved. No unreviewed safety or environmental questions are involved.

2 EC-20 72 The adjustment of the No. 24 Main Steam Header Hangers to a new load setting in no way creates a new safety hazard.

There are no changes to the Tech. Specs. or the UFSAR involved. No unreviewed safety or environmental questions are involved.

  • Design Change Request

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  • DCR NO. 10CFR 50.59 SAFETY EVALUATION 2HC-0364 The change in the upper and lower bearing oil fill piping will not affect the operation of the motors. This will r.ot involve any change to the FSAR or the Tech. Specs. No unreviewed safety or environmental questions are involved.

2SC-0388A The modifications to the quench lines affect systems that are. not safety related. They will not alter any plant process or discharge and will not affect the existing plant impact. No unreviewed safety or environmental questions are involved.

2SC-0420 The modifications to the Service Water pump motor bearing coolers do not change the function of the coolers. All supports have been redesigned and re-evaluated as necessary. The change will prevent corrosion and/or erosion of the pipe thereby increasing the reliability of the aystem. This also reduces the possibility of service water leaking into the environment due to a pipe failure.

No unreviewed safety or environmental questions are involved.

2SC-0949 This DCR addresses drawing changes only. No modification I of any control logic or affect of any installed safety related equipment is involved. No unreviewed safety or environmental questions are involved.

2SC-1093 This change eliminates a severe safety hazard of utilizing temporary scaffolding (inadequate support) to get up to the level of the hatch or the batching tank. The new platform is seismically qualified. No previous structural safety analyses are adversely affected. No unreviewed safety or environmental questions are involved.

2SC-1168 This change involves the replacement of an existing transmitter. All realistic, potential failure modes.have been considered but are not applicable. No unreviewed safety or environmental questions are involved.

2 SC-1172 A The valve replacement involves only non-safety related

, systems. The modification will not alter any plant j process or discharge and will not affect the existing plant impact. No unreviewed safety or environmental questions are involved.

  • Design Change Request l

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  • DCR NO. 10CFR 50.59 SAFETY EVALUATION 2SC-1269 The telescoping ladders and platforms to be used conform to ANSI standard A92.3-1980. Seismic restrtints are provided to negate the effects that a seismic event would have on the platforms while they are in the stored position. The modification will not alter any plant process or discharge and will not affect the existing plant impact. No unreviewed safety or environmental questions are involved.

2SC-13 86 The addition of gland leak off lines on the Heater Drain Pumps do not affect any presently performed safety analysis, nor does it create any new hazards. The modification will not alter any plant process or discharge

! and will not affect the existing plant impact. No unreviewed safety or environmental questions are involved.

2 SC-15 80 The removal of the lever, the forked lever and the spindle nut from the affected valves will not affect the intended operation of the valves. The component removal will not

! result in a violation of Section III since the pressure j setpoints will not be affected. The lif ting levers on

! safety valves have been deleted from ASME Section III Code

! since 1977, since all utilities (including Salem) have an l Inservice Inspection Program to test MSSV once per i refueling outage. Also, the environment in a nuclear I power plant is much cleaner than that of a fossi power I plant which precludes oxidation of the nozzle / disc area preventing sticking or galling. Thus, the need for manual  !

lifting levers is obviated. No unreviewed safety or environmental questions are involved.

  • Design Change Request ,

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PSE&G SALEM GENERATING STATION SAFETY RELATED WORK ORDER LOG SALEM UNIT 2 WO NO DEPT UNIT EQUIPMENT IDENTIFICATION 8505172345 SMD 2 23 TAC PUMP FAILURE DESCRIPTION: TRIED TO START 23 TAC PUMP AND BREAKER TRIPPED FREE.

NO FLAGS WERE FOUND. PLEASE INVESTIGATE AND REPAIR.

CORRECTIVE ACTION: REMOVED BREAKER SN#0224A6260-007, INSTALLED BREAKER l

SN#0224A269-002. ONLY WORK DONE ON THIS WO WAS TO INTERCHANGE BREAKERS. SEE WO #8505231465 FOR WO ON FAILED BREAKER.

8505131720 SIC 2 22BF4 0 FAILURE DESCRIPTION: VALVE HAS A BLOWN DIAPHRAM. PLEASE REPAIR.

CORRECTIVE ACTION: REPLACED DIAPHRAGM OF CONNECTED REGULATOR AND GAUGE l

TO. VERIFY PROPER STROKE AND CALIBRATION. VERIFIED PROPER OPERATION.

8505140605 SIC 2 PRESS. SPRAY VALVE

- FAILURE DESCRIPTION: THE VALVE IS LEAKING BY CAUSING PRESSURIZER PRESSURE TO RESPOND SLOWER THAN NORMAL. PLEASE REPAIR.

CORRECTIVE ACTION: CALIBRATED E/P TRANSDUCER. STROKED VALVE FROM l

CONTROL TO VERIFY LIMIT INDICATIONS.

8505120213 SIC 2 SHUTDOWN ROD 2SA1 l

FAILURE DESCRIPTION: WHILE PULLING SHUTDOWN BANK "A" ROD 2 sal DID NOT INDICATE MOVEMENT. PLEASE CHECK AND REPAIR.

CORRECTIVE ACTION: FOUND AND OPEN ON WIRE 1 & 2 ON TB5 IN CAB 22AC, 2SA1 ROD.

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. SALEM UNIT 2 l WO NO DEPT UNIT EQUIPMENT IDENTIFICATION l 8'505120019 SIC 2 DORIC POINT 101 i FAILURE DESCRIPTION: POINT FOR DISCllARGE OF BORIC ACID FILTER'IS FAILED THIS' POINT IS ON VITAL HEAT TRACE SURVEILLANCE.

MAINTENANCE DEPARTMENT PLEASE REPAIR.

CORRECTIVE ACTION: FOUND LEADS LIFT ON SATELLITE FOR DORIC' TESTING. ,

REIANDED LEADS AND VERIFIED CORRECT READING.

8505070712 1 l SMD 2 21 WASTE GAS COMP HREAKER FAILURE DESCRIPTION: BREAKER TRIPPED,. SPRINGS ARE DISCIIARGED.. PLEASE INVESTIGATE.

CORRECTIVE ACTION: REPLACED MOTOR COMPLETED M32.

l 8505081013 '

SIC 2 CONTROL ROD FAILURE DESCRIPTION: THIS ROD IS OUT OF SPEC. WITl! Tile REST OF T!!E DANK.

PLEASE CIIECK.

CORRECTIVE ACTION: RECALIBRATED SIGNAL CONDITIONING MODULE AND BAILEY INDICATOR. INDICATION WITilIN LIMITS Al"rER

- CALTHRATION.

8505011384 SMD 2 21AP119 l

FAILURE DESCRIPTION: VALVE IS LEAKING THRU, PLEASE REPAIR.

CORRECTIVE ACTION: INSTALLED PIPE CAP ON NIPPLE. LEAK STOPPED.

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. SALEM UNIT 2-WO MO DEPT UNIk' EQUIP 9GbiT IDENTIFICATION .

8504300323 SIC 2 21S/G STM FLOW CH. 2 FAILURE DESCRIPTION: STM FLOW CHANNEL 2 IS READING ERRACTICALLY. PLEASE INVESTIGATE AND REPAIR. ,

t CORRECTIVE ACTION: FOUND INDICATOR OUT OF SPEC. CALIBRATION AND RETURNED TO SERVICE.

f 8504082288 SIC 2 RAD. MONITOR FAILURE DESCRIPTION: THE INDICATION FOR THIS CHANNEL IS ERRATIC. PLEASE ,

i CHECK.

CORRECTIVE ACTION: CLEANED CONNECTIONS ON REMOTE CONTROLLER SN-215 AND COMPLETED CHANNEL FUNCTIONAL TEST.

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i 0099158426 SMD 2 24 SW PMP FAILURE DESCRIPTION: 24 SW PMP STRAINER HAS A PACKING LEAK.

CORRECTIVE ACTION: INSTALLED 3 RINGS PACKING 2 RINGS CORTEX.

0099158329

- SIC 2 1D4 ROD POSITION IND BEZ FAILURE DESCRIPTION: 1D4 CONTROL ROD INDICATION APPEARS TO BE DRIFTING. L

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CORRECTIVE ACTION: REPLACED METER MOVEMENT AND AMPLIFIER IN BEZEL INDICATOR. CALIBRATED INDICATOR AND SIGNAL MODULE.  !

INDICATOR WAS CHECKED THE NEXT DAY NO DRIFTING ALL  !

SAT. I

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l SALEM UNIT 2 j

i WO NO DEPT UNIT EQUIPMENT IDENTIFICATION 0099157632 SMD 2 25 SW PMP FAILURE DESCRIPTION: THE PACKING ON THE PMP IS LEAKING.

CORRECTIVE ACTION: REPACKED PUMP AS PER WORK ORDER WO 8505290704 TO REPLACED PACKING SLEEVE.

0099016991 SIC 2 PLANT VENT PROCESS MON FAILURE DESCRIPTION: HIGH - LOW DEVIATION ALARM FLOW UP. PLEASE INVESTIGATE AND REPAIR.

CORRECTIVE ACTION: PLACED DAUL CONTROLLER FOR MANUAL AND ADJUSTED SAMPLE FLOW TO 4.6 CFM.

0099015986 SIC 2 COND POLISHER MONITOR l

l FAILURE DESCRIPTION: ALARM REQUIRED INDICATION FOUND OUT OF SPEC DURING CHANNEL CALIBRATION PROCEDURE AND CHANNEL LOCKS UP WHEN ATTEMPTING TO INPUT SIGNAL AT TEST LOCK.

' PLEASE INVESTIGATE AND REPAIR.

CORRECTIVE ACTION: INSTALLED NEW TEST JACK. PERFORMED CHANNEL CAL

- CHECK PROCEDURE 2PD-4.5.063. PERFORMED CHANNEL CAL PROCEDURE 2PD-4.1.063.

7 SALEM GENERATING STATION MONTHLY OPERATING

SUMMARY

- UNIT NO. 2 MAY 1985 SALEM UNIT NO. 2 The period began with the Unit operating at 50% power with adjustments to 422 Steam Generator Feed Pump in progress. On 5/02/85 at 0916 .

hours the Unit tripped due to loss of excitation to the Generator which resulted from improper wiring of the Loss of Excitation relay circuitry. Synchronization occurred on 5/4/85 at 1615 hours0.0187 days <br />0.449 hours <br />0.00267 weeks <br />6.145075e-4 months <br />. On r 5/8/85 at 1348 hours0.0156 days <br />0.374 hours <br />0.00223 weeks <br />5.12914e-4 months <br />, power was reduced to approximately 80% to remove a leaking valve and cap a line on the Stator Water Cooling System.

The Unit was returned to full power operation at 1500 hours0.0174 days <br />0.417 hours <br />0.00248 weeks <br />5.7075e-4 months <br /> the same day. . On 5/10/85 at 1712 hours0.0198 days <br />0.476 hours <br />0.00283 weeks <br />6.51416e-4 months <br />, the Unit tripped as a result of High Negative Flux Rate. During routine Control Rod operability surveillance testing, Control Rod 2C4 dropped due to a poor electrical connection. The Unit was returned to service at 0305 hours0.00353 days <br />0.0847 hours <br />5.042989e-4 weeks <br />1.160525e-4 months <br /> on 5/15/85 following repairs and inspection of all Control Rod Connectors. Full power operation was achieved at 0256 hours0.00296 days <br />0.0711 hours <br />4.232804e-4 weeks <br />9.7408e-5 months <br /> on 5/16/85 where it remained for the rest of the period.

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ID <,.

REFUELING INFORMATION DOCKET NO.: 50-311

. COMPLETED BY: J. Ronafalvy UNIT NAME: Salem 2 .

DATE: June 10, 1985 TELEPHONE: 609/935-6000-EXTENSION: 4455 Month May 1985

1. Refueling information has changed from last month:

YES X NO

2. Scheduled date for next refueling: ' September 6, 1986-
3. Scheduled date for restart following refueling: November 16, 1986
4. A) Will Technical Specification changes or other license- t amendments be required?

YES NO Not determined to date B) Has the reload fuel design been reviewed by the Station Operating Review Committee?

YES NO X  ?

If no, when is it scheduled? August 1986

5. Scheduled date (s) for submitting proposed licensing action:

August 1986 if required

6. Important licensing considerations associated with refueling:

NONE

7. Number of Fuel Assemblies:

A) Incore 193 i B) In Spent Fuel Storage 140 >

8.

Present licensed spent fuel storage capacity: 1170 Future spent fuel. storage capacity: 1170 I

9. Date of last refueling that can .be discharged to spent fuel pool assuming the present-licensed capacity: March 2003 8-1-7.R4 i

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F-O PSEG Public Service Electric and Gas Company P.O. Box E Hancocks Bridge, New Jersey 08038 Salem Generating StLtion June 10, 1985 Director, Office of Inspection and Enforcement U.S. Nuclear Regulatory Commission Washington, DC 20555

Dear Sir:

MONTHLY OPERATING REPORT SALEM NO. 2 DOCKET NO. 50-311 In Compliance with Section 6.9, Reporting Requirements for the Salem Technical Specifications, 10 copies of the following monthly operating reports for the month of May 1985 are being sent to you.

Average Daily Unit Power Level Operating Data Report Unit Shutdowns and Power Reductions Major Plant Modification Safety Related Work Orders Operating Sumary Refueling Information Sincerely yours, L,i,>

~

J. M. Zupko, Jr.

General Manager -

Salem Operations JR:sbh cc Dr. Thomas E. Murley Regional Administrator USNRC Region I 631 Park Avenue King of Prussia, PA 19406 Director, Office of Management Information and Program Control U.S. Nuclear Regulatory Commission Washington, DC 20555 Enclosure 8-1-7.R4

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